Well testing device, rathole type



Jan. 28, 1941. A. BoYNToN WELL TESTING DEVICE, RATHLE TYPE Filed Oct.28. 1958 4 Sheets-Sheet l Ja'n. 28, 1941. A. BoYNTON wELL 'rEsTm-EnEvIcE, RATEOLE TYPE Filed oct. 28.' 195e 4 Sheets-Sheet 2A A fron/VHS,

Jan. 28, 1941.

A. BOYNTON WELL' TESTING DEVICE, RATHOLE TYPE Filed Oct. 28, 1938 4Sheets-Sheet 3 /lZlE/V OH,

ATTORNEYS.

4| 4 ALEXANDER 50mm/v,

ige zz 4 Sheets-Sheet 4 Af BoYNToN WELL TESTINGv DEVICE, RATHOLE TYPEFiled oct. 28, 193s Jan. 28, 1941.

lPatented Jan. 28, 1941 UNITED STATES PArl-:N'r OFFICE wnLnrEs'riNdizifnarnonnmn l I Alexander Boynton, San Antonio, Tex.

Application October 28, 1938, Serial No. 237,524

17 Claims.

This invention relates to improvements in well testing devices in whicha packer, packer landing means, clutch, latch. flare chamber, va1ves,toexclude well uid -from the drill stem and to 5 allow pumpiiuid to bedischarged thru it and to entrap test fluid in the drill stem, andan-instrument housing case are formed into an assembly to be run into anuncased well for the purpose of ascertaining the nature Aand quantity of:Huid

l which the well would produce if casing be set and the well completed.

It is important that temperatures and pressures of producing formationsbe ascertained.

Some testing tools, such as those which employ l shear pins, fractureplates, or left hand threads, have to be manually conditioned andreadjusted for each test, which entails trouble, expense, and

lo'ss of time. This device employs no left hand threads, requires noleft hand rotation, has no v gears, shear pins, or fracture plate, andvmakes no use of falling weights, godevils,or other uncertain means tooperate it. All parts of this device automatically resume their normalpositions in readiness for another test as soon as the packer is liftedvfrom. its seat at vconclusion of the preceding test.

In order:l to overcome the foregoing dangers and difficulties,y the mainobjects of this invention are to provide a formation testing devicefordrilled or drilling wells, which device has the following advantages:o

First-That it may be safely run into, and readily withdrawn from a wellfor the purpose of recovering a measured sample of the wells productionfrom the horizon below where the packer is set.

Second- That the drill stem or other pipe upon which the device is runmay be rotatedfrom top to bottom, including the device itself, while itis 40 being lowered into or being withdrawn from the well.

Third-That the drill stem may be 'rotated above the packer during aproduction test while the packer remains stationary.

Fourth-That the device may be pumped through at any time.

Fifth-That it affords means for signalling the operator when mud orcavings that should be rotated through or pumped out have beenencountered as the devicey is being lowered into op erating position.

Sixth-That it enables the packer to be re- Y-peatedly let down upon itsseat until the -best possiblemeal-oif has been obtained before'the Vtestis begun by opening the intake ports.

(Cl. 16B-1) Seventh-That it minimizesv resistance from mud fluidin thewell while it is being lowered and while the packer is being lifted fromits seat, and while the device is being-withdrawn from the well, byallowing part of the mud fluid to f5l y pass through the packer at allsuch times. Eighth- That it automatica1lyreturns all of its parts totheir normal positions when the drill stem is raised at conclusion ofeach test. thus enabllng that lthe tests may berepeated as often w asdesired, by raising the drill'stem slightly and formations in lorder toestimate the production thereof may be now `largely dispensed with by 25employing this device to actually determine the future production whichcores frequently indicate inaccurately. A

Twelfth-That, in effect, by temporarily producing from the well beforecasing is set, the 30 great financial risk of completing unproductivewells may be denitely avoided.

With the foregoing, and other related objects in view, reference is nowmade to the drawings, in which Fig. 1 isan outside view ofthe device ina well bore, showing the packer seatedupon the rathole.

Fig. 2 is a longitudinal section of the upper portion of'the preferredform of the invention.

Fig. 3 is a longitudinal section ofthe lower 40 portion of the preferredformof the invention completing the part shown in Fig. 2.

Fig. 4 is a transverse section on the line I-I, Fig. 3.

Fig. 5 is a longitudinal section of. an upper 45 portion of the deviceshownl in Fig. 3, showing Fig. a'. Y 5t Fig.,9 is a transverse sectionon the line 9-9, Fig. 2.

Fig. 10 is a transverse section on the line i0- i, Figs. 5 and 11.

Fig. 11 is a longitudinal section of a portion of the rst modified formof the invention, otherwise the same as the preferred form as shown inFigs. 2 and 3. In order to complete this modiiled form of the inventionthe illustration in Fig. 11 between the lines a-a and b--b will beconsidered as replacing that portion of the construction shown in Figs.2 and 3 between the lines a-a and bb.

Fig. 12 is a perspective View in longitudinal section vof the art 31 inFig. 2.

Fig. 13 is a rspective view in longitudinal section of the part 39 inFig. 2.

Fig. 14 is an outside view ofthe part l1 in Fig. 2.

Fig. 15 is a longitudinal section of a portion of the device shown inFig. 11, illustrating the packer as seated upon a rathole in a well boreand showing the intake ports open as during the formation test.

Fig. 16 is a longitudinal section of the upper DOItion of the secondmodified form of the inin Fig. 16.

Fig. 18 shows a portion of the device illustrated in Figs. 16 and 17inserted in a Well bore with the packer seated upon a rathole and .theintake ports open as during a formation test.

Fig. 19 is a transverse section on the line i9-i 9, Fig. 16.

Fig. 20 is Fis'. 16.

' Fig. 21 is a transverse section on the line 2 i-2 I, Fig. 146.

Fig. 22 is a transverse section of the line 22-22, F18. 16.

23 is a transverse section on the line 23--23,

Fig. 24 is a transverse section on the line 24-2 I,

a transverse section on the line 20-29,

Fig. 25 is a longitudinal section in perspective of the shell upper endin Fig. 16.

Fig. 26 is a perspective view oi.- a portion of the nippleV in Fis. 16.v

Fig. 27 is atramverse section on the line 21-21, Y

The same reference characters are employed to Y refer to the same partsthroughout the several views. In Fig. l, the preferred form of theinvention is shown inserted in a well bore a, with the packer .seated atc upon the rathole b, the drill stem 43 being connected to member il bycoupling u. The device may be said to consist of the lowing units orassociation of parts: A

The outer shell consists o! latch clamp member l. nipple 2, couplingmember l, nipple 5, reducing coupling ,nipple 1, connection member 9,having longitudinal ribs 3a, nipple 9, and bottom plug il, havingopenings Ila.

- The inner string consists of a drill Stem conperspective nectionmember i i nipple i5, having wrench slots lia: connection member i6,clutch shell i1, nipple i8, member I9, connection member 26, valveactuating nipple 21, and intake port carriernipple 21B.

The packer 28, Fig. 2, which may be of rubber, leather, belting washers,or other tough, durable substance, is illustrated as consisting of aplurality of belting washers 28a fitted over the lower portion of packercarrier nipples 1 and locked against upper retaining member 29 by lowerretaining member 30, having threaded connection over the member 8, themember 29 being secured upon nipple 1 by welds 29a and 29h.

Pressure equalization by fluid communication between the rathole belowthe packer and the bore above the packer while the Packer is beingseated, is very important in order to prevent the packer seat from beingcut'by the fluid that would otherwise be forced out between the packerand the seat; but such equalization is still more important while thepacker is being raised from its seat.

This pressure is equalized the moment theV drill stem is raised farenough to open valve 21a in the preferred form, or valve 21Aa in thefirst modified form, or valve 93e uncovering ports 61h in the secondmodified form. In all three forms it will be noted that these valves,respectively, are opened before any lifting force is exerted upon thedril-l stem; and therein resides oneof the most important features ofthis invention.

The openings 1a and 8b and the annular space y within nipple 1 andmember 8 provide for circulation through the packer while it is beinglowered into or being withdrawn' from the well, and while the packer isbeing seated. This cir-- culation path is closed when valve 21a entersthe upper end of member 8 as appears in Fig.- 5, the member 21a having aclose sliding ilt within the upper end of member 8.

In addition to equalizing the pressure above and below the4 packerduringl the seating operation, as well as making it easier to lower andraise the packer `in the well bore, the openings la and 8b and theannular chamber g,which provides communication between them, alsolargely overcomes the danger of the packer sticking or becoming fast inthe rathole, because these openings cause the pressure to equalize onboth sides of the packer as soon as the valve 21a is raised out of itsengagement within the restricted area in the member 8, which occursbefore any unseating pull is exerted upon the packer.

Well fluid is excluded from .the drillt stem before the packer is set bymeans of check valve 33 normally engaging its seat 21Bb upon the lowerend of nipple 21B by expansive force 4of spring 49 engaging undersupport 42 having a'central depression upon its upper surface withinwhich check valve 33 rests. When the check valve is unseated by/ pumppressure the pump fluid passes out of themember. 3i through slots 3Ic,in the tubular extension 3Ib. It will be noted that the upper end of themember. 3| is formed into a piston having peripheral grooves Bia. 'I'hispiston has a close sliding ilt within nipple 9. The ring 32 secured uponnipple 21B by weld 32a formsa shoulder against which piston 3i locks inits threaded engagement uponnipple 21B. The puryit out through .thelower openings Illa.

pose of this piston is to prevent pump uid from passing out throughopenings 9a, thereby forcing The expensive force of spring .I9 is aidedby the pressure ofwell fluidexterior of the device in causof the pumpfluid will be downward through the inner string and check valveassembly, past the instrument case 45, and out through openings Illa inbottom member I0. Manifestly, this bottom end member may be replaced bya bit of such size as will enter the rathole if, in lowering the tool,mud or cavings should require the use of a bit.

Inlet ports 2IBa are normally closed by the close sliding fit which thenipple 21B has within the member 8, as appears in Fig. 3. After thelatch has been sprung, the packer has been seated upon the rathole, andthe drill stem has been communication between the ports 'Ia and 8b toyrotated part of a turn clockwise, as will be later explained, the intakeports 21Ba move downward out of -themember 8, and assume the positionshown in Fig. 5. Well fluid from the rathole then enters the drill stemthrough inlet openings 9a and intake ports 2'IBa, as also appears lnFig. 5. It will be noted that communication between the pressureequalizing openings 1a and 8b is closed by valve 21a while the device.is intaking -test fluid. At conclusion of the intaking period, which isusually from 15 to 45 minutes, the inlet ports are closed when the drillstem is raised, at the same time lifting the nipple 21B to permitequalize the pressures above and below lthe packer. This occurs whilethe packer is still seated, andbefore any lifting force is exerted uponit. because the lower pockets Ill, Fig. 14, which engage the clutchballs 38 at completion of thev upward telescopic movement of the innerstring within the outer shell permit enough movement to cause intakeports 21Ba to become sheathed within the member 8 as appears in Fig. 3.

Latch balls 36 received Within circular recesses Ict-34a in the latchclamp member I and the' sleeve 34 as seen in Fig.r 2 are resilientlyengaged between the ball rider ring I4 and ball floor ring 35 by theexpansive force of latch spring 50. Latch spring base 3, secured withinlatch spring housing nipple 2 by means of welds 3a, supports ,spring 50,which spring, installed under compression, urges the latch to closedposition and the entire device to its most elongated position, whereinclutch balls 38'engage within lower pockets I'If thereby arresting thetelescopic elongation. The recesses Id-34a should preferably be formedto fit the contour of the latch balls and should be of a depth slightlyless than one-half the diameter of the balls. If the recess Id-34a is asdeep or deeper than one-half the diameter of the balls, the balls willimpinge between the ring I'4 and the recess 34a, and thereby render thelatch inoperative. The latch balls may be 1% to 1%" in diameter. If theballs are 11e" in diameter, 5/04" to 3%" depth of the groove Ill-34awill be found satisfactory. The ring I4, which may be pressed upon thelower end of member II preferably should be of hardened steel; likewisethe balls, ring 35, and sleeve 34 should be hardened. The sleeve 34 has4a close expansive force ofvspring 50, which urges the steeply inclinedsurface 35a against the balls, thereby impinging them upon the' recessId.

When the latch is sprung, by weight of theY drill stem, the balls ridedownward between the rings I4 and 35, and in doing so, engage innersurfaces of sleeve 34 and nipple 2. It will. be noted that the uppersurface of the ring 35 is of two angles. The steeper or latching anglesurface 35a engages the balls While they are imbedded in the recess Id-34a, as stated; thus imparting Ygreat force to the engagement. Whenthe balls are forced out of the recess as the latch springs, they engageupon the more hor-izontal or unlatching angle surface 35h, the angle ofwhich is such as will return .the balls into their recess Irl-34a whenthel latch returns; but at the same time will not urge the balls outwardwith enough force to score the inner wall of nipple 2. f

Assuming that the latch balls are' within the circular recess I d-34a toa maximum depth of slightly less than one-half'the diameter of theballs, the latch may be adjusted to be sprung by the application of lessforce `by lessening the depth that -they are allowed to enter thisrecess. The less they enter it, the easier they can be forced out of it.Suchadjustment may be made by screwing the nipple 2 upward in couplingmember 4; locking ring 2a being employed tc secure the adjustment. Inmaking such adjustment, it can be observed that the ring I4 is not alsoforced upward as thenipple 2 is forced upward because the clutch balls38 engaging .the lowermost pockets IIf of slots I'Ib do not permit suchmovement. It is apparent that another purpose of spring 50 is toautomatically return the latch to engaging position after the forcewhich springs it has been released.

The latch and clutch chamber d, Fig. 2, closed at its upper endv byconnection member lI I, slidable within the member I, and closed at thelower end by member 26, may be lled with a lubricant to providelubrication for the latch and clutch. This lubricant may be suppliedthrough the openings shown closed by plugs` 48 land 5I, Fig. 2'.

The clutch in Fig. 2, is shown in its normal engaged position, as whenbeing lowered into or being withdrawn from the well. This clutchl isformed of shell I1, balls 38, upper ball socket base 31, and lower ballsocket base 39. The upper base 31 having slots 31a, Fig. 12, forcirculation ofv a lubricant within the annular chamber c,

may be pressed into clutch coupling member 4v and landed upon theinternal shoulder 4a, Fig. 2, the flutes 3lc-. being imbedded within theinner wall of thisv coupling member. The lower ball socket base39,"havi'ng circulation slots 39a, Fig. 1'3, similar to, and'aligningwith, the circulation slots-31a, is removably tted closely within themem-ber 4 for convenience in assembling and taking `thefclutch apart.The lowerv base 39 is held in 'place by the threaded engagement `betweenmembers 4 and 5,' as appears in Fig. 2. The clutch balls 38 are receivedfor one-half of their diameter within sockets 3Ib and 39h, Figs. 12 and13,.and extend for the other half of their diameter into the slots Ilb,Fig. 14, formed by the several short ribs llc and the one long rib |11'.These slots, like the sockets, have a common depth equal toapproximately one-half the diameter of the balls '38. The slots are openat their upper ends and are of irregular shape in their closed lowerends where they are formed into pockets Ilf, conforming to the balls.The upper portion of reduced external diameter I1a provides the annularspace I1h, Fig. 2, also having a uniform depth equal to one-half thediameter of the balls.

The shell I1, therefore, is longitudinally and rotatably movable withinlimits imposed by the slots Ilb and the annular space I1h; longitudinalmovement being permitted by the slots and the rotatable movement beingpermitted by the turned oiI portion Ila. The balls 38, while free torotate in their respective sockets, cannot leave their sockets because,as stated, the slots Ilb and annular space Ilh have a common depth equalto one-half the diameter of theballs. The lower base 39; otherwise free,is locked with upper base 31 by the balls imbedded equally within themating sockets 31h and 39D, Figs. 12 and 13; and since the flutes 31eare securely imbedded within the coupling member 4, it is apparent thatthe inner string and outer shell of the device are locked togetheragainst independent rotation as long as the balls remain within theirrespective slots Ilb. I'he downward movement of the inner string atbeginning of the test after the packer has been seat-L ed, places theannular space I1h opposite the balls This movement disengages theclutch. The drill stem may be then freely rotated upon rollers a,leaving stationary the outer shell, packer, and all other parts belowthe thrust bearing. The clutch is always so disengaged while the deviceis intaking test fluid, because the valve travel is determined by thetravel of. the member 26, having its downward movement stopped bylanding floor Ia; this travel being sulllcient to place clutch balls Ilopposite the turned off portion I'Ia above the upper end of longest ribIIi, which movement disengages the clutch.

At conclusion of the test, there is no danger that the ribs may impingeupon the balls due to some possible error in spacing the upper wedgeshaped ends of the ribs, because the one rib I'li is longer than theothers and, therefore, acts as a pilot to guide the other ribs betweenthe balls.

In the return movement of shell I1 the sloping surfaces I1e, Figs. 2 and14, automatically guide the clutch balls into their lower pockets lll.The expansive force of latch spring Il, aided by the weight of themovable shell of the device, plus the resistance oil'ered to raising thepacker-'from its seat in the ratholel accomplishes this quick andautomatic return of all parts to their normal positions at conclusion ofeach test.

The external flange IIa engaging under the internal flange Ila of theclutch shell member I! holds the thrust bearing top 2l; rollers 25a, andthrust bearing bese 2i assembled by the threaded engagement betweenclutch shell member Ii and connection member 2G., Packing 2l, gland 2 I,and

spring 23, adjustably held by clamp cap 22, threadedly engaged over theupper extension II, provide that the thrust bearing will notpermit'leakage linto or out of the drill stem. Y

The upper pockets IId engage the clutch balls instantly after the latchSprings. A slight clockwiaerotationofthedrillstemwillthenforcethe''downwardly inclined surfas llaoverthe balls until the upperstraightportionof slots I1bregister in vertical alignment with the balls. Thedrill stem then moves downward by force of gravity until the member 26lands on floor 6a, Fig. 2, This travel, as stated, is such as will placethe turned ol portion Ila above the longest rib |11', at which time thedrill stem may be rotated independently of the packer and other partsbelow the thrust bearing during the test intaking period. The method oflanding the packer will be discussed in connection with operation.

The lower portion of connection member I6 immediately above the clutchshell has slight clearance, such as 11; to M5" within the nipple 2, thisclearance being for free passage of a lubricant, which preferably shouldbe placed within the chamber d for lubrication of the latch and clutch.

The lower piston-like end ofthe member I I and the other piston-likemember 26 should preferably be of the same diameter, in order that thelubricant in chamber d will move freely between the pistons withoutimpinging them on one stroke or causing a vacuum to be pulled betweenthem on the other stroke, as would result if one piston were of greaterdiameter than the other.

It should be observed here that the clutch is always engaged while thelatch is engaged, and vice versa. If mud or cavings be encountered whilethe device is being lowered into the well, the same may be washed out bypumping thru the device or drilled out by rotating the drill stem. Ifthe latch springs while the drill stem is being rotated, the drillsterrrshould be then raised slight ly to re-engage the latch. Rotationmay be then resumed without danger of disengaging the clutch and openingthe intake ports until the latch is again sprung. The latch, as stated,may be set to withstand as much weight as desired before it will thedevice is being lowered, will enable the packer spring. Ordinarily,rotating the drill stem while' th" device is being lowered. will enablethe packer to be seated in the rathole without having it employ the,pump. If, however, it should be necessary to rotate the drill stem andpump thru it at the same time, both may be done, -If pumped thru, thedrill stem, of course, must be emptied by hailing, swabbing, or bywithdrawing it from the well before a clean test sample can be obtained.

The annular chamber IIc is a flare chamber, which may be illled with aare liquid of different color from the well fluid, red or yellow leadpaint being generally satisfactory. The expanded portion IIb, havingperipheral grooves Ila, of the member II has a close sliding piston ntwithin the ilare chamber shell Ia and the lower portion of member I Ihas a close sliding piston nt within the central portion of member I-above and below packing I3. Well fluid pressure entering thru pressureports Ic, causes packing I3 to closely engage upon the member II. Theflare fluid is placed in chamber IIc thru openings Ib shown closed byrubber band I2. When the drill stem y settles within the outer shell, asthe intake ports are opened by a partial clockwise rotation and slightsettlement of the drill stem, it is apparent that the flare fluid willbe forced out of chamber IIc thru discharge ports Ib, the rubber band I2yielding to permit such escape. When the drill stem is raised within theouter shell after the intaking period of the test, well fluid will enterthe chamber llc thru openings Ib, the rubber band I2 yielding orrupturing to permit such entrance.

If it be desired to employ more flare fluid than that contained inchamber Ilc, the chamber e, 1113.2. mayalsobenlledwlthnarenuld thrutneopenings 1a, which openings may be then closed with a rubber bandsimilar to the one employed :to close the openings Ib. y

If two telltale substances of different colors be discharged each at adi'erent level above the packer, presence in the test sample of thelower telltale fluid only will indicate that the packer leaked ronlyslightly, but if both telltale substances are found in the testv fluid,it will be apparent vthat the leak past the packer was of greatervolume.

'Ihe member y26, having peripheral grooves 26a, has a close piston twithin the nipple 5 and serves to confine the latch and clutch lubricantwithin the chamber d, as well as to determine the-va1ve travel bylanding upon oor 6a. The breather openings 'Ia provide that themember-26 will not impinge upon fluid in the chamber e on the downwardstroke or pull a vacuum therein on the upward stroke, as is apparent.

The instrument case 45, Fig. 3, having lateral openings 45h, has a lowerrod-like extension 45a, which has its lower end of reduced diametersecured within a central opening thru Bottom end member I by mea-ns ofnut 4|. Studs 46, are secured within the case by welds 46a. The cover 40is secured by nuts 41. Instruments may be placed' in the case 45 forrecording pressures andtemperatures obtaining in th'e Well. Well fluidin thel rathole below the packer enters the instrument case thru loweropenings a and lateral openings 45b.

In operation the device is shown'in Fig. 1 as positioned in the wellbore a, by means of drill stem 43 and coupling 44, with the packerengaged at c upon the rathole b. The full weight of the drill stem, osas'much thereof as necessary, is allowed to force the packer intoengagement with the seat c upon the rathole. 'I'his engagement must besuch thatl well uid above the packer will not migrate downward past thef packer while the device vis intaking test fluid.' In order to causesuch engagement it is generally desirable that the packer be landed uponthe rathole several times. Each time the packer lands the latchwill'spring and the upper pockets/Hd will engage the clutch balls 38.Each time the drill stem israised the lower pockets Hf will engage theballs, -and each time it is lowered the upper pockets I'Id will reengagethe balls, this travel ordinarily being /2 to 2, and not enough tocause, the intake ports 21Ba to pass out ofthe lower end of member 8.When the operator is satisfied that ,the-packer Y has been properlyseated, the drill stem igrotated -clockwise pant of a turn moving thedownwardly inclined surfaces Hg, Figs. 2 and 14, upon-the balls 38untilthe balls become vertically aligned with the. upper portion ofslots l'lb. The drill stem then settles by its own 'weight until themember 26 lands upon floor 6a. y'

In this movement the intake pont carrier nipple 21B is forced downward.until intake ports 21BA are uncovered (s ee Fig. 5) .Y Well uid from therathole then enters the drill stem via inlet 9a, the annular chamber f,and intake ports 21Ba. -These ports are again closed by the reversemovement of .thenipple 21B when the drill stem is raised at conclusionof the ltest, thereby entrapping within the drill stem the productionfrom the rathole during the period of thetes't. In order to repeat suchtests in rapid succession without withdrawing the drill stem from thewell, the packer may be raised from its seat, thereby causing the intakeports to be closed; whereupon the test fluid may be bailed or. swabbedout, after This may be done.

Opel'- this manner a formation test is made to positively discloseAwhere-the test fluid came from.

When the device is withdrawn from the well, in addition to learning 'theamount and physical properties ofthe production, it is also desirable toknow the temperature at `different levels, as-

well as the temperature variations which obtained in the ltestedformation during the test,

and also the pressures and variations in pressures which obtained thereduring that time.

If the operator checked his time; with the timing mechanism of .therecording instruments and kept a record of the timewhen'the device 'wasat different levels going in and coming out of the well, as shouldalways be done, `the above information will be found in the instrumentcase, from which the instruments may'be removed by unscrewing bottom endmember I0 and removing the lid or cover 40. 7

If the test should reveal unwanted production in the rathole,cementslurry' may be pumped through the device and into the formation tobe plugged, in which event the cement will take the reverse path, tothat indicated for the Vtest fluid, as plainly appears in Fig. 5.

\ The first modified form of theinvention shownin its normal position ofthe parts in Fig. 11, and

seated upon a rathole intaking test fluid in Fig.

taining a leak proof sliding nt with the nipple 21C; nipple 53,connection member 55,l nipple 9, and other parts below theline b-b thesame as .in Fig'. 3.

The inner string consists of rvalve actuating nipple 21A having valveZ'IAa. formed upon its lower end; intake ports carrier nipple 21C,threadedly 11 and 15, and other parts above the line a-a the same asin'Fig. 2.

The packer 18A, similar to the packer of the preceding form, may be ofrubber, leather, belt- 'ing, or Aany other tough, 'durable substancev astion, as appears in Fig. 1,1, to provide, during such times that wellfluid may circulate through the or allowed to entrap mud rings to aid inmainjoined together, as appears in Figs.

packer. This communication through the packer nipples 21A and 21C, andopenings 8Ab oontinues until interrupted by the entrance of the lowerend of nipple 21A into the shell BAd, within which it has a closesliding t, just before the seating of valve 21Aa upon its seat BAc, atwhich time all communication through the packer betweenthe Well bore andbelow it terminates. This interruption of pressure equalization aboveand below the packer, occurs as the packer is seated. Raising the drillstem after valve 21M seats far enough to' withdraw the Alower end ofnipple 21A out of the shell'SAd will always instantly re-establishequalization of p pressure above and below the packer. The length of theshell 8Ad need be only such as will guide the valve ZlAaupon its seat8Ac.

The check valve 52 having radial arms 52A engaging upon the upper end ofspring 54, is urged upon its seat 21Ca in the lowerend of nipple 21C bythe expansive force of spring 54, which is supported upon the connectionmember 55. This valve serves to exclude well iiuid from the drill stemand to allow the drill stem to be pumped through, as was explained forthe check valve shown in the preceding form.

The nipple 21C has a close sliding fit within the lower end of member8A, which thus'pro'vides means for normally maintaining the intake ports21Go, closed as appears in Fig. 11.

When the packer lands the latchA springs, the drill stem is rotatedclockwise part of a turn and the clutch disengages, as was explained forthe preceding form, valve 21Aa lands upon its'seat 8Ac and the intakeports 21Cb open by being forced downward far enough toi uncover belowthe member 8A, as appears in Fig. 15. In this position of the intakeports test fluid from the rathole enters through openings 10a (see Fig.3), passes around the instrument case, around the check valve assembly,and enters the drill stem through the intake ports 21Cb.

'I'he first modified form may be operated-in the same manner' and forall of the purposes as stated for the preferred form to which referenceis here made. A

-In the second modied form, Figs. 16 and 17, a similar number ofcorresponding units to those employed in the preferred form, but havingsomewhat different construction. are employed in a similar manner as inboth preceding forms accomplish the same result. v

The outside shell of the second modified form, having limited telescopicmovement over the inner string, consists of latch vclamp member 51,latch adjusting nipple 58, connection member 6I, locking ring 69, nipple62, threaded upon member 6I, and secured thereon by welds 62a; `nipple63, coupling member 64, nipple 65, connection member 66, packer nipple61, connection member 68, nipple 69, and bottom end member I9.

The inner string consists of drill stem connection member 1l, adapted tobe threadedly en-l gaged upon the drill stem 43, in the same manner asindicated for the preferred form in Fig. 1; upper clutch key nipple 16,having special wrench slots 16d; bearing housing member 82, clutch basesupport 86, lower clutch key nipple 88, connection member lol, clutchshell 9|,nipple 92, and valve actuating nipple 93.

A packer element 99, such as was described for the preferred forms ofthe invention, is closely flttedover the nipple 61' where it ispositioned between its upper retaining member 97, secured v upon nipple91 by welds 91a and 91h, and its via ports 1Aa, the annular spaceexterior of lower retaining member 98, adapted to engage the packerelement closely against the member 91 by means of the threadedengagement of member 99 upon nipple 61.

Pressure of well fluid equalizes above and below the packer thruopenings 91h and 61o and the annular space f, Fig. 17. This pressureequalizing communication continues'while the device is being loweredinto the well or being withdrawn therefrom and while the packer is beingseated upon the rathole. If, in securing a good seat for the packer, itshould be necessary to make repeated landings of the packer upon therathole,

lthis may be done without closing the equalizing passages at any time,because when the latch springs the lugs 99, Figs'. 16 and 30, arrest thdownward movement of the inner stringbefore the intake ports 68hareunoovered by the downward movementof sleeve valve 94, as will be morefully explained. The valve 93e cuts 0E pressure equalization above andbelow the packer when it `moves downwardly far enough to close ports 61hbefore the intake ports 68h are uncovered. Pressure equalization aboveand below the packer is re-established when the, drill stem is raiseduncovering parts 91o at conclusion of the intaking period and before anylifting force is exerted upon the packer. The packer and outer shell arelifted by the drill stem when the lugs 99 are engaged by the irregularbottomends of slots 9lb in the upward movement of the drill stem atconclusion of the intaking period.

It being. always understood that the drill stem is empty when employedto lower the device into a well for a formation test, a check valve isprovided to exclude well uid therefrom until the .within the dependingtubular shell 93a of the actuating nipple 93 and has a similar flt overthe upstanding tubular extension 68a of the member 68. The coiled spring95, supported by ring 96, is freely movable within the annular spacebetween extension 68av and the shell 93a and nor- -mally urges the valve94 upon its seat 93h, which seat it never leaves except when pumppressure forces it downward, compressing spring and uncovering ports66o, at which time iiuid from the pump passing downwardly thru the drillstem, moves thru the annular space between the solid upper end 69e andshell 93a, thru the ports 58h, and downwardly thru the tubular extension68a, whence it passes around the instrument case A, andout thru theopenings 19a of the bottom end member i9. Manifestly the expansive forceof spring 95 should be such as will safely return the valve 94 toengagement upon its seat 93h and such as will not allow this valve to beunseated by the weight of the test uld as the drill stem is withdrawn atconclusion of the intaking period.

0f course, a bit, ordinarily of the fish tail type,

may be substituted for the member i9 if cavings or settlings are apt tobe encountered before the packer is landed.

When the packer has been properly landed, a

slight clockwise rotation of the drill stem frees the inner string,which descends and forces .the valve member 94 downwardly past theintake ports 58h, as appears in Fig. 18. In this position of the portstest fluid from the rathole enters th-epdrill stem via pressureequalizing ports 81o,

annular space f, intake ports 68b, and the annular space surroundingextension 68e. The travel necessary to force the sleeve 94 downward farenough to uncover the intake ports, as shown in Fig. 18, is determinedby the distance between the lower end of clutch shell 9| and the landingfloor 66a, upon which the member 9| lands to stop the downward movementof the inner string. Manifestly, the member IUI could be landed upon thelugs 98 to limit the valve travel, instead of landing the shell 9| uponthe oor 66a, as just stated; the choice of which said means to-employ,

in limiting the valve travel being a matter of construction preference.'o

'Ihe latch assembly consists of ball rider ring 12, latch balls 13, ballfloor ring 14, and a circular groove having a depth of slightly lessthan onehalf the diameter of the latch balls, onehalf of said groovebeing formed within the member 51 and the other half thereof beingformed within the upper end of the sleeve 10, as

` appears in Fig. 16. This latch is so similar to vthe latch shown anddescribed in connection with the preferred form thatreference is madethereto. The latch in this modiflcationmay be adjusted to engage withless force than when the latch balls are fully engaged within theirgroove by screwing the nipple 58 upward upon the member 6|, therebyforcing the latch balls to `engage less deeply within their recess aswas also explained for the preferred form. The locking ring 68 may beemployed to lock the nipple 58 so as to secure the latch in any adjustedposition;

`A oating clutch is shown ,in-Fig. 16. Thisv clutch consists o f shellupper end member'11, havingl internal longitudinal ribs 11a. and 11bwith tapered lower ends, and forming slots 11e,

(see Fig. 25) -shell 81 threaded upon the inember 11, and welded theretoat 11e; lower end member y89, vhaving internal longitudinal ribs 89a and89h withtapered lower ends 89d, and

i'orrning slots 89e; upper clutch key nipple '15,

having keys 16h with wedge shaped upper ends 15e; lower clutchkey nipple88, having keys 88a -4withwedge shaped upper ends 88h, (see Fig. 26);

and. the thrust lbearing consisting of members 853-84 and 85.` The upperclutch keys 16h and lower clutch keys 88a are. shown to be exactlyalike, and the ribs and slots of4 the upper end member '11 are'similarto, the ribs and slots of o the lo'werend member 89.

The clutch shellis housed within the nipple 62, and contained thereinagainst movement between the lower end of connection member 6| and upperend oi-nip ple 83. ,The

.shell has slight. end clearance between member 6| and -nipple 53,andfalso' slight lateral clearance within thenipple 62. The upper clutchmale keys 16h, .of equal length,'have an easy sliding t within the slots`11c ,'(see Fig. 25) and the lower clutch keys 88a, each of equallength, have an easy sliding t within the 4slots 89e.' Fig. 16. Bothupper and lower keys and slots are normally engaged, as shownin Fig. 16,which engagement causes the entire drillstem above and below the thrustbearing-to be lockedtogether as a unit against independent rotation.,

jIn operatiomthe upper andV lower sets of male keys are thrust downwardwhen the inner string longitudinal moves downward after the latch hasbeen sprung and the drill stem has been rotated part of a clockwiseturn, as explained. This downward movement, which causes the intakeports 68h to be opened, as appears in Fig. 18, places the keys entirelybelow the slots.` The clutch is then 4disengaged and the drill stemabove the thrust bearing may be rotated independent of all other parts.The packer and the entire outer shell of the device from its lowerextremity up to and including its upper member 51, remains stationarywhile the clutch is disengaged and ldrill stem is rotated.

The clutch being disengaged, if the drill stem be then raised, theclutch and latch will become re-engaged by the expansive-force of latchspring 15, aided by the weight o'f. the outer shell of the device, plusthe force requiredto pull the packer out of its seat in the rathole. The'tapered lower ends 11d, Fig. 25, of the upper ribs and the taperedlower ends 89d, o! the corresponding lower ribs will guide the upper andlower keys back into their engaged position within slots 11c and 89erespectively. Two of these ribs, the upper one being 11b of the upperend member 11, and the other one being rib 89h, of the lower end member89, extend downward below their combase 85, and rollers-84. This bearingis made leak proof' by packing 8| engaged by gland 80 urged upon thevpacking by spring 19 held in place bythe cap 18.- Itwill be observedthat r after the intake ports the longitudinal slots B2b, in theinternal flange 82a,V Fig. 16, and the similar slots 18a in the internalflange 18`b, inthe -cap 18, Fig. 2l, are adapted to admit and pass overthe male clutch keys 1Gb for conveniencein assembling the partsI 18 and82 over the upper clutch key nipple 18 and its` keys. .The gland 8U isin halves shown I lcut in two at a, Fig. 16, also -to enable assembling.o Means for landing the packer is shown proximate'the lower end. Fig.16. Thelugs, Fig.. 29,

removably fitted within the sluts 64e, Fig. 2s,

and secured therein against rotation by internal ribs 54a, havingthroughthem slots 84h for cir.- culation ot-a lubricant, have their shell elocked between the nipples 88 and 85, Fig. 16. Each` o i these lugs isfreely received within the lower irregular shaped portions of slots 9|by -formed by and between ribs 9|a, Fig. 30. These irregularportionsconform-to the shape of the lugs, except that the lugs havespace. for limited upward 'movement in the lower end of these slots,

as clearly appears in Fig. 30 where a lug, par-4 tiallybroken away, isshown yplaced in one of the slots 9|b. The distance between the uppersteps 80a, Figs. 29 and 30, and their opposing steps 9|c.- in the shell8|', Fig. 80, is equal to the distance between lower steps'i\90b andtheir opposing steps 9|d. This distance between the steps ot the lugsand the steps in' the shell is such that when these steps e iggethefshell 9| may be slightly rotated clockwise to bring the lugs into f.f the lower ends of the'straight portions of the "slots 9Ib, at l'whichtime 'the weight of the drill a "if, l f

stem will force the shell 9| downwardly far enough to open the intakeports, as appears in Fig. 18.

The packer may be landed upon the rathole as often as necessary toobtain a good seat, as stated. Each timethe packer lands the latch willspring and the lugs 90 will engage their steps 90a and 90b upon theopposing steps 9|c and 9Id -of the clutch shell, Fig. 30. Each time thedrill stem is raised slightly the latch will reengage and the lugs willmoveto engage the lower irregular shaped ends of the slots as alsoappears in Fig. 30. The packer being properly landed, the drill stem isrotated clockwise, causing, the lugs to register with the straightportions of the slots, whereupon the drill stern settles, opening theintake ports as stated, and thus .begins the intaking period of thetest. l

The distance between the lugs and their upper opposing steps or seats 9Ic and 9 Id when the lugs are in the position shown in Fig. 16, shouldbe less thanA the travel necessary to disengage the clutch, lfor theobvious reason that il the clutch should disengage before the lugsengage on their upper landings the drill stem wouldV turn upon thethrust bearing and, therefore, could not then be employed to place thelugs 99 and slots 9|b in vertical alignment for the purpose ofinitiating the valve movement necessary to allow intaking of test uidthrough the ports 68h.

It will be noted that the steps 90a are each formed with asloping uppersurface indicated by the angle 9|lc, Fig. 29, this angle being the samefor both steps. The steps 9|c and 9|d in the shell 9| each have theirupper surfaces formed. with a mating slope conforming to the angle 99e.This angle inclines so that the drill stem will be raised slightly as itis rotated clockwise-part of a turn. These mating engaging surfacesprovide that the lugs and their upper steps or landing places willalways engage when the latch springs, and that they will not bedisengaged unless the drill stem be rotated, as stated. The distancebetween the steps 99av and 90b of the lugs and their opposing steps 9Icand Qld of the shell, Fig. 30, are not only thel`v same, but these stepsare each of equal width. When the drill stem -is rotated part of a turnclockwise, in order to bringthe lugs and the upper straight portion ofthe slots 9|b into perpendicular alignment, it is apparent that twoslight drops of the drill stem will take place; the rst drop occurringwhen the lower steps 90p move to engage the upper steps 9|c while theupper steps 90a move into the slots 9|b. This drop will be one to twoinches, such being the usual length of the steps. The second downwardmovement of the drill stem will occur when the drill stem has beenrotated clockwiseslightly further, at which time the lower steps 90bdisengage from .the upper steps 9|c and all of the lugs 90 enter theslots SIb. This second downward movement of the drill stem causes theclutch to disengage and the intake valve to open as has been previouslyexplained.

When the drill stem is raised at conclusion of the intaking period, theinclined surfaces Sie, Fig. 30, each being at the same angle, will guidethe lugs, then having their lower sloping surfaces 98d landed upon theinclined surfaces Ble, back into the positionhshown in Fig'. 16.

The latch clamp member 5l has a close sliding fit over the connectionmember 7|. v.Packing 56 is compressed against member '1| by well iuidacting through pressure ports 57a. The annuaaaaeae lar chamber d' withinthe nipple 58 and member 6I. Fig. 16, may be filled with a lubricant ofsuch color as will identify it from the well fluid as was explained forthe preferred form. cant, in addition to easing the action of the latch,in the chamber d', serves as a nare, which will be forced out throughthe discharge ports 58a and past rubber band 59 by member 1|, when theintake valve opens.

Such displacement occurs because the member 1I is of somewhat greaterdiameter than the piston-like lower end of member 9|. Manifestly, wellfluid will be drawn into the chamber d' when the member 1| returns tothe position shown in Fig. 16 at conclusion of the intaking period. Thischamber should be drained and refilled with flare fluid each time thedevice is withdrawn from the well. Such drainage and refilling may beaccomplished through the openings shown closed by band 59. The chamberd", Fig. 16, may be also lled with a lubricant for the clutch and'-lparent that the chamber e', Fig. 1'7, may be also filled with a flarefluid and the breather openings 61a closed with an elastic band, such asthe one shown at 59; thereby replacing or supplementing the use ofchamberd' for the-purpose of discharging flare fluid above the packer.

The instrument case held in place byV nut 4| andindicated generally atA, Fig. 17, being substantially the same as the one shown in Fig. 3 ofthe preferred form, reference is made to that specication.

The purposes and operation of the second modified form is like thatdescribed for the preceding forms to which reference is made.

It is understood that all references to positions and directions such asupper" and lower. upward and downward, above and below apply to the toolas illustrated in the accompanying drawingsV wherein the upper portion'of the tool is shown uppermost.

It is understood that the details/f construction 'and arrangement ofparts are subject to many obvious variations and minor changes withoutdeparting from scope and purpose of my invention as defined' by theappended claims.

I claim:` A

1. A tool of the character described including an operating pipe, ashell thereon, a packer fixed to said shell to seat in the well bore andsupport vsaid shell, ports in said shell4 above and below said packer, arestricted b ore in said shell between said ports so as to allow fluidpassage between said ports, and an enlargement on said pipe to move intosaid restricted bore to separate the areas in said bore above and belowthe pack- 2. A tool of the character described including an operatingpipe, a shell thereon, a packer xed to said shell to seat in the wellbore and support said shell, ports in said shell' above and below saidpacker,'a restricted bore in said shell between said ports so as toallow uid passage between said ports, an enlargement on said pipe tomove into said restricted bore to separate the areas in said bore aboveand below the packer, and additional registering ports on said pipe andshell to admit fluid to said pipe from below said 3. A tool of thecharacter described including This lubrian operating pipe, a shellthereoma packer xed to said shell to seat in the well bore and supportsaid shell, ports in said shell above and below said packer, arestricted bore in said shell between said ports so as to allow iiuidpassage between `said ports, an enlargement on said pipe to move intosaid restricted bore to separate the areas in said bore above and belowthe packer, and a latch between said shell and pipe to be released uponmovement oi said pipe relative to the shell.

4. A tool of the character described including an operating pipe, ashell thereon, a packer fixed to said shell to seat inthe well` bore andsupport said shell, ports in said shell above and below said packer, arestricted bore in said shell between said ports so as to allow fluidpassage between said ports, an enlargement on said pipe to move intosaid restricted bore to separate the areas in said bore above and belowthe packer, and a clutch between said shell and pipe to be released uponmovement of said pipe relative to the Shell.

5. A tool of the character described including an'operating pipe, ashell thereon, a packer fixed to said shell to seat in the well bore andsupport said shell, ports in said shell above and below said packer, arestricted bore in said shell between said ports so as to allow uidpassage between said ports, an enlargement on said pipe to move intosaid restricted bore to separate the areas in said bore above and belowthe packer, and a latch and clutch between said shell and pipe to bereleased upon movement of said pipe relative to the shell.

6. A string of pipe, a shell slidable thereon, a latch to normallyprevent sliding of said shell, spaced ports in said shell, a packerbetween said ports, a valve memberon said pipe, and means in said shellto receive said member to prevent a flow between said ports.

'1. A string of pipe, a shell slidable thereon, latch to normallyprevent sliding of s aid shell,

' spaced ports in said shell, a packer between said ports, a. valvemember on said pipe, means in said shell to receive said member toprevent, a ow between said ports, and additional ports on said pipewhich are normally covered by said shell but uncovered 'when said pipeslides relative to said shell whereby uid from the well bore below saidpacker is admitted to said pipe.-

8. A string 'of pipe, a shell slidable thereon, a latch to normallyprevent sliding of said shell, spaced ports in said shell, a packerbetween said ports, a valve member on said pipe, means in said shell toreceive said member to prevent a ow between said ports, additional portson said -f pipe which are normally covered by said shell but uncoveredwhen said pipe slides relative to said shell whereby fluid from the wellbore below said packer is admitted to said pipe, and a check valve toclose said pipe against inflow irrespective of movement of said pipe.

9. A string of pipe, a. shell slidable thereon, a latch to normallyprevent sliding of said shell,

` spaced ports in said shell, a packer between said# ports, a valvemember on said pipe, means inports, a valve member on said pipe, meansin `said shell to receive said member to prevent a Viiow between saidports, and telescoping Sleeves on said pipe and shell adapted forrelative movement by said pipe to admit well fluid from below saidpacker, one of said sleeves being'upstanding from said shell to t withinsaid pipe sleeve.

11. An operating string of drill stem or pipe, a

-shell adapted tov have limited telescopic move- -ment over the lowerportion of said pipe, a

packer on said shell, pressure equalizing ports l in said shell aboveand below said packer, intake ports for test fluid in said shell belowthe packer, a portion ofsaid shell being formed into a sleeve throughwhich a portion of said. pipe is closely slidable, intake ports insaidpipe, said ports being normally closed by said sleeve, three pistons onsaid pipe, two chambers for' flare fluid, one under each of two'of saidpistons, telltale fluid in each of said two chambers, a latch adapted toreleasably engage said pipe and shell, a clutch adapted to releasablyengage said pipe and shell,

a thrust bearing in said pipe below the clutch, a check valve upon thelower end of said pipe, said valve being adapted to permit pump fluidfrom 2 above the well to pass through the drill stem and lment over thelower portion of said pipe, a packer on said shell, pressure equalizingports in said shell above and below said packer, intake ports for testuid in said shell below the packer, a`

portion of said shell being formed into a sleeve, intake ports in saidpipe, said ports being normally closed by said sleeve, a check valveuponthe lower end of said pipe, said valve being adapted to permit pumpiiuid from above the well to pass through the drill stem and to preventwell iiuid from entering the same, and means for lifting the packer'from its seat while closing the intake ports without closing thepressure equalizing ports.

13. An operating string of drillstem or pipe, a shell adapted to havelimited telescopic movement over the lower portion of said pipe, apacker on said shell, pressure equalizing ports insaid shell above andbelow said packer, intake ports for test fluid in said shell below saidpacker, a connection member on said shell formed into a sleeve over alower portion of said pipe, a valve on said pipe adapted to engage aseat within said sleeve, intake ports in said pipe, said ports beingnormally closed by said sleeve, two pistons on said pipe, a chamber forflare fluid under one of said pistons, a piston in said-chamber,telltale -fluid in `said chamben-a latch adapted to releasably engagesaid pipe and shell, a clutch adapted to releasably engage said pipe andshell, a thrust bearing in said pipe below' the clutch, a check valveupon the lower end of said pipe, said valve being adapted'to permit pumpfluid from' above the well to pass through said pipe and to prevent welluid from entering the same,'an lnstrument case in s aid shell below thepacker, and means for lifting the packer from its seat while said shellabove and below said packer, intake ports for test uid in said shellbelow said packer, a -connection member of said shell formed into asleeve over a lower portion of said pipe, a valve on said pipe adaptedto engage a seat within said sleeve, a clutch adapted to releasablyengage said --pipe and shell, intake ports in said pipe, said portsbeing normally closed by said sleeve; 'a check valve upon the lower endof said pipe, said valve being adapted to permit pmnp iiuid from abovethe well to pass through the pipe and to prevent well iiuid fromentering the same, and

means for lifting the packer from its seat while closing the intakeports without closing the pressure equalizing ports.

15. An operating string of drill stern or pipe, a

'shell adapted to have limited telescopic movement over the lowerportion of said pipe, a packer on said shell, pressure equalizing portsin said shell above and below said packer, a portion of said shell abovethe packer formed into a sleeve for a tubular piston valve, a tubularpiston valve on'said pipe slidable in said sleeve and adapted to closethe upper equalizing ports of said shell, a tubular member upstandingwithin said shell, the upper end of said tubular member being closed,lateralopenings in said tubular member below its closed upper end, asleeve check valve adapted to prevent well fluid from entering saidpipe, said valve being slidable over said tubular member and alsoslidable within said pipe and being adapted to uncover discharge portsfor pump iiuid when the same is forced through said pipe, said portsalso being intake openings for test iluid when the packer is set and thepipe is rotated to disengage the clutch, two additional pistons in saidpipe, a chamber for flare :duid under each of said two pistons, telltalesubstances aaaacse in each of said chambers, said substances being ofdierent colors, a latch adapted to releasably engage said pipe andshell,- a clutch adapted to releasably engage said pipe and shell, athrust bearing in said pipebelow the clutch, an instrument case in saidshell below thepacker, and means for lifting the packer from its seatwhile the intake openings are closed-without closing y the pressureequalizing ports.

16. An 'operating string of drill stem or pipe, a shell adapted to` havelimitedrtelescopic movement over the lower `portion of said pipe, apacker v on said shell, pressure equalizing ports in said e shell aboveand below said packer, a portion of said shell above the packerformedinto a sleevev for a tubular piston valve, a vtubular piston valveon said pipe slidablein said sleeve and adapted torclose theA upperequalizing portsY of said shell,

a tubular member u p'standing withinsaid shell, '26.

the upper end of said tubular member being closed, lateral openingsinsaid tubular member p member and also4 slidable within saidspipe andbeing adapted to uncover discharge ports for pump fluid when the same isforced through said pipe, said ports also being intake openings for testiiuid when the packer is set and the pipe is rotated to disengage theclutch, and means for lifting the packer from its seat while the intakeopenings are closed without closing the pressure equalizing ports. f

17. In atool of the character described, a string of voperating pipe, ashell having limited telescopic movement over the lower portion thereof,a packer on said shell, means for equalizing pressure above and belowsaid packer at all times when the tool is -not intaking test fluid,means for admitting test uid after the packer is set, and means forclosing the tool to admission of well iiuid when the packer is raisedfrom its seat.-

ALEXANDER BOYNTON.

